Method and system for purification of natural gas using membranes

ABSTRACT

Natural gas may be purified by removing C 3+  hydrocarbons and CO 2  in respective first and second gas separation membrane stages to yield conditioned gas lower in C 3+  hydrocarbons and CO 2  in comparison to the un-conditioned natural gas.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a Continuation of U.S. patent application Ser. No.15/367,477, filed Dec. 2, 2016, which is a Continuation-In-Part of U.S.Non-Provisional patent application Ser. No. 14/984,615, filed Dec. 30,2015 which claims the benefit of priority under 35 U.S.C. § 119 (e) toU.S. Provisional Patent Application No. 62/262,652, filed Dec. 3, 2015,the entire contents of each of which are incorporated herein byreference.

BACKGROUND Field of the Invention

The present invention relates to the purification of natural gas usinggas separation membranes.

Related Art

Water, carbon dioxide, hydrogen sulfide and heavy hydrocarbons arecommon contaminants for natural gas. During the gas conditioningprocess, these contaminants are removed so that the natural gas can beused onsite or transported to the pipeline. Depending upon whetheremissions of the reject gas from such a gas conditioning process aresubject to governmental regulation, the reject stream from the gasconditioning process may be flared. The reject stream may instead bere-injected deep underground, thus producing near zero air emissions.

The conditioned gas has to meet certain natural gas pipelinespecifications, such as a carbon dioxide concentration below 2%(vol/vol), a C₃₊ hydrocarbon dewpoint of no more than −4 OF (−20° C.),and an H₂S concentration of less than 2 ppm. The water concentrationshould be below 7 lb per million std ft³ per day (11.2 kg per millionstd m³ per day) and sometimes as much as below 5 lb per million std ft³per day (8.0 kg per million std m³ per day). Additionally, the C₃₊hydrocarbon content of the conditioned gas should be limited so that theBTU/caloric content of the conditioned gas is about 950-1050 Btu(240-265 kcal).

In the event that the reject stream is re-injected deep underground, ithas to be dry in to avoid corrosion of the injection line and theformation of hydrocarbon hydrates. The water content for the reinjectedstream has to be below 50 ppm (vol/vol) and sometimes as low as 1 ppm(vol/vol).

In the natural gas conditioning process, gas separation membranes arenormally utilized for carbon dioxide removal due to their relativelysmall foot print and light weight and their relatively high energyefficiency. Gas separation membranes can generate conditioned gas with asuitable moisture content. However, the reject gas is at a relativelylower pressure and it is of course enriched with water. The conventionalsolution is to first dehydrate the unconditioned feed gas with amolecular sieve and then treat the dehydrated gas with a gas separationmembrane purification step. This type of hybrid process can indeed meetthe specifications for both the conditioned gas and gas to bere-injected. However, the relatively high footprint, volume, and mass ofthe molecular sieve dehydration process are a concern for many naturalgas conditioning applications, especially for off shore applicationswhere the footprint, volume, and capacity to withstand massive equipmentare at a premium.

It is well documented that glassy polymers, such as polyimide,polysulfone, polybenzimidazole, etc., exhibit exceptional high intrinsicCO₂/methane selectivity. However, the selectivity and permeance of themembranes prepared from those materials often quickly decrease once theyare used for natural gas conditioning in the presence of C₃₊hydrocarbons. This loss of membrane performance is caused bycondensation of the C₃₊ hydrocarbons on the membrane surface. Theconventional solution for this problem is to use a system including amolecular sieve and carbon trap for removing the C₃₊ hydrocarbonsupstream of CO2 removal. Although these pretreatment systems caneffectively remove heavy hydrocarbons from the natural gas stream, thecost of the pretreatment sometime can be prohibitive. Indeed, the costof the pretreatment system can be as high as 50% of the total systemcost (pretreatment plus membrane).

SUMMARY

There is disclosed a method for purification of natural gas includingmethane, CO2, and C₃₊ hydrocarbons. The method comprises the followingsteps. A feed gas consisting of the natural gas is fed to a first gasseparation membrane stage comprising one or more membranes in series orparallel having a selective layer that is selective for C₃₊ hydrocarbonsover methane. A first permeate stream is withdrawing from themembrane(s) of the first stage that is enriched in C₃₊ hydrocarbons incomparison to the feed gas. A first retentate stream is withdrawn fromthe membrane(s) of the first stage that is deficient in C₃₊ hydrocarbonsin comparison to the feed gas. The first retentate stream is fed to asecond gas separation membrane stage comprising one or more membranes inseries or parallel having a selective layer that is selective for CO₂over methane. A second permeate stream is withdrawn from the membrane(s)of the second stage that is enriched in CO₂ in comparison to the feedgas. A second retentate stream is withdrawn from the membrane(s) of thesecond stage that is deficient in CO₂ in comparison to the feed gas.

There is also disclosed a system for purification of natural gasincluding methane, CO2, and C₃₊ hydrocarbons, comprising: a source ofnatural gas; a first gas separation membrane stage comprising one ormore membranes in series or parallel fluidly communicating with saidsource, each membrane of the first gas separation membrane stage havinga selective layer that is selective for C₃₊ hydrocarbons over methane;and a second gas separation membrane stage comprising one or moremembranes fluidly in series or parallel communicating with a retentateoutlet(s) of the membranes of the first gas separation membrane stage soas to receive retentate from the first gas separation membrane stage asa feed gas in the second gas separation membrane stage, each membrane ofthe second gas separation membrane stage having a selective layer thatis selective for CO₂ over methane.

The method and/or system may include one or more of the followingaspects:

-   -   water is removed from the feed gas prior to feeding the feed gas        to the first gas separation membrane stage.    -   said water removal comprises feeding the feed gas to a molecular        sieve adapted and configured to remove water from fluids.    -   said water removal comprises feeding the feed gas to a        dehydration gas separation membrane.    -   the first and/or the second permeate streams is combusted as a        flare gas.    -   the feed gas is obtained from natural gas extracted from a        subterranean or subsea geological formation and said step        further comprises injecting the first and/or second stage        permeate streams into the geological formation.    -   the first and/or second permeate streams are dehydrated prior to        injection into the geological formation such that a water        content in the first and/or second permeate stream injected into        the geological formation is no more than 50 ppm (vol/vol).    -   each of the one or membranes of the first gas separation        membrane stage have a separation layer made of a copolymer or        block polymer of tetramethylene oxide, and/or propylene oxide,        or ethylene oxide.    -   a pressure drop between a pressure of the feed gas and a        pressure of the retentate gas is less than 50 psi (3.45 bar).    -   a pressure drop between a pressure of the feed gas and a        pressure of the retentate gas is less than 30 psi (2.07 bar).    -   a pressure drop between a pressure of the feed gas and a        pressure of the retentate gas is less than less than 20 psi        (1.38 bar).    -   the one or more membranes of the first gas separation membrane        stage have a methane permeance of less than 68 gas permeation        units (22.4 mol/m²·sec·Pa).    -   the one or more membranes of the first gas separation membrane        stage have a methane permeance of less than 34 GPU.    -   the one or more membranes of the first gas separation membrane        stage have a methane permeance of less than 20 GPU.    -   the one or membranes of the first gas separation membrane stage        have a separation layer made of a copolymer or block polymer of        the formula:

-   -   where PA is an aliphatic polyamide having 6 or 12 carbon atoms        and PE is either poly(ethylene oxide) poly(tetramethylene        oxide).    -   the one or membranes of the first gas separation membrane stage        have a separation layer made of repeating units of the following        monomers:

-   -   the separation layer of the membranes of the second gas        separation membrane stage is a polymer or copolymer selected        from cellulose acetate, polysulfones, and polyimides.    -   the separation layer of the membranes of the second gas        separation membrane stage is a polyimide essentially consisting        of repeating units of dianhydride-derived units of formula (I)        and diamine-derived units

-   -   where each R is the molecular segment of formula (3)

each Z is the molecular segment of formula (5),

20% of the diamine-derived units are the diamine-derived moiety ofeither formula (A) or formula (B) and 80% of the diamine-derived unitsare the diamine-derived moiety of formula (C), where when thediamine-derived moiety of formula (A) is the case, only one of X₁, X₂,X₃, and X₄ is a methyl group and the others are hydrogen, and where whenthe diamine-derived moiety of formula (B) is the case, only one of X₅,X₆, X₇, and X₈ is a methyl group and the others are hydrogen:

-   -   each of the one or more membranes of the first gas separation        membrane stage are formed as flat films or as a plurality of        hollow fibers.    -   each of the one or more membranes of the first gas separation        membrane stage has a separation layer that is supported by a        support layer.    -   each of the support layers is made of a polyimide, polysulfone,        or polyether ether ketone.    -   each of the support layers is porous and is made of polyether        ether ketone.    -   each of the membranes of the second gas separation membrane        stage is made of cellulose acetate, a polysulfone, or a        polyimide.

BRIEF DESCRIPTION OF THE DRAWINGS

The FIGURE is a schematic of the method and system of the invention.

DESCRIPTION OF PREFERRED EMBODIMENTS

Natural gas may be conditioned with gas separation membranes so as tomeet desired levels of C3+ hydrocarbons, CO₂, and optionally H₂S. Theunconditioned gas may optionally be pre-treated with a molecular sieve(or equivalent dehydration technique) upstream of the gas separationmembranes in order to dry the unconditioned gas prior to membraneseparation. The conditioning process includes feeding the feed gas(i.e., the unconditioned natural gas which has optionally beendehydrated with a molecular sieve or equivalent dehydration technique)to a first gas separation membrane stage.

A feed gas of natural gas or conditioned (i.e., dehydrated) natural gasis fed as feed gas stream 1 to one or gas separation membranes of thefirst gas separation membrane stage 3 in series or parallel. A firststage permeate stream 5 is withdrawn from a permeate side of the firstgas separation membrane stage 3 and a first stage retentate stream 7 iswithdrawn from the feed gas side of the first gas separation membranestage 3. The membranes of the first gas separation membrane stage 3include a selective layer that is selective for C₃₊ hydrocarbons overmethane. By “selective for C₃₊ hydrocarbons over methane”, we mean that,as a whole, the C₃₊ hydrocarbons become enriched in the permeate stream5 in comparison to the feed gas 1 and the C₃₊ hydrocarbons dewpoint ofthe retentate is lowered. Those skilled in the art of gas separationmembrane technology will recognize that the C₃₊ hydrocarbons dewpoint isthe temperature at which cooling of the retentate 7 will causecondensation of C₃₊ hydrocarbons.

The first retentate stream 7 is fed to a second gas separation membranestage 9 containing one or more gas separation membranes in series or inparallel. The membranes of the second gas separation membrane stage 9include a selective layer that is selective for CO₂ over methane. Asecond stage permeate stream 11 is withdrawn from a permeate side of thesecond gas separation membrane stage 9 and a second stage retentatestream 13 is withdrawn from the feed gas side of the second gasseparation membrane stage 9.

If flaring of the first and/or second stage permeate streams 5, 11 isprohibited due to environmental regulations or if it is economical orotherwise desirable to not flare such streams, it may be re-injecteddeep underground (or in the case of subsea natural gas extraction, deepunder the seabed). In the event that the first and/or second stagepermeate stream 5, 11 contains too high of a moisture content to allowre-injection as is, such a stream may first be dehydrated by anysuitable technique for gas dehydration to reach a moisture content of nomore than 50 ppm (vol/vol) and as low as 1 ppm (vol/vol).

If flaring is otherwise allowable and desired instead of re-injection,the first and/or second stage permeate stream 5, 11 may be combusted asa flare gas with or without additional separate flare gases associatedwith other gases collected in the natural gas extraction andconditioning processes.

The separation layer of each of, or at least one of, the gas separationmembranes the first gas separation membrane stage 3 may be made of acopolymer or block polymer of tetramethylene oxide, and/or propyleneoxide, or ethylene oxide. These types of polymers exhibit modestproductivity (i.e., permeance) for methane and preferential permeationof C₃₊ hydrocarbons. Due to the modest methane productivity of thesepolymers in comparison with silicone based polymers, membranes with lowmethane productivity for methane can be conveniently achieved. Throughselection of a separation layer with modest methane productivity andpreferential permeation of C₃₊ hydrocarbons, for the membrane(s) of thefirst gas separation stage membrane 3, only a relatively low pressuredrop across the first gas separation membrane stage 3 (i.e., thedifference in pressure between the feed gas 1 and the retentate gas 7)may be realized. As a result, there is no need for recompression of thefirst retentate 7 before it is fed to the gas separation membrane(s) ofthe second gas separation membrane stage 9. Typically, the pressure dropbetween the feed gas 1 and the retentate gas 7 is less than 50 psi (3.45bar). The pressure drop may be less than 30 psi (2.07 bar) or even lessthan 20 psi (1.38 bar). Typically, the membrane productivity for methaneshould be below 68 GPU (22.4 mol/m²·sec·Pa). Often, it is below 34 GPUor even below 20 GPU.

Copolymers or block polymers of tetramethylene oxide, and/or propyleneoxide, or ethylene oxide may be conveniently synthesized, such as thepolyester ether disclosed in U.S. Pat. No. 6,860,920, the polyesterethers of which are incorporated by reference.

where PE may be one or more of the following structures:

Other copolymers or block polymers of tetramethylene oxide, and/orpropylene oxide, or ethylene oxide may be conveniently synthesized, suchas polyimide ether disclosed in U.S. Pat. No. 5,776,990, the polyimideethers of which are incorporated by reference.

The copolymers can be further obtained by copolymerization of acrylatedmonomers containing oligomeric propylene oxide, ethyelene oxide, ortetramethyelene oxide. Commercially available copolymers includepoly(ether-b-amide) multiblock copolymers available from Arkema underthe trade name of PEBAX, and poly(butylene terephthalate) ethylene oxidecopolymer available under the trade name of Polyactive.

Typically, the PEBAX polymers from Arkema include PEBAX 7233, PEBAX7033, PEBAX 6333, PEBAX 2533, PEBAX 3533, PEBAX 1205, PEBAX 3000, PEBAX1657, or PEBAX 1074. PEBAX 1657 exhibits a methane permeability of 5.12Barrer. H. Rabiee, et al., J. Membrane Sci. vol. 476, pp. 286-302(2015). In contrast, PDMS exhibits a methane permeability of 800 Barrer.Stern, et al., J. Appl. Polym. Sci., Vol. 38, 2131(1989). The PEBAXpolymers have the following general chemical structure:

Where PA is an aliphatic polyamide “hard” block (nylon 6 [PA6] or nylon12 [PA12], and PE denotes a polyether “soft” block, either poly(ethyleneoxide) [PEO] or poly(tetramethylene oxide) [PTMEO].

Commercial available PolyActive multiblock copolymers have the followinggeneral chemical structure:

While the gas separation membrane(s) of the first gas separationmembrane stage 3 may have any configuration known in the field of gasseparation, typically they are formed as a flat film or as a pluralityof hollow fibers. In one embodiment, the separation layer is supportedby a support layer where the separation layer performs the desiredseparation while the support layer provides mechanical strength. In thecontext of hollow fibers, the separation layer is configured as a sheathsurrounding a core made of the support layer. Regardless of theconfiguration of the membrane, the support layer may be any poroussubstrate known in the field of gas separation membranes and includesbut is not limited to, polyimides, polysulfones, and polyether etherketones. Typical hollow fiber membrane supports are PEEK poroussubstrate fibers commercially available from Air Liquide AdvancedSeparations, a unit of Air Liquide Advanced Technologies, US.

Typically, the gas separation membrane(s) of the first gas separationmembrane stage 3 includes membranes commercially available from Medalunder the trade name PEEK-SEP.

The separation layer of the membrane(s) of the second gas separationmembrane stage 9 may be made of any polymer or copolymer known in thefield of gas separation membranes that is selective for CO₂ overmethane. Typically, the separation layer of the membranes of the secondgas separation membrane stage 9 is made of cellulose acetate, apolysulfone, or a polyimide. Typically, the polyimide essentiallyconsists of repeating units of dianhydride-derived units of formula (I)and diamine-derived units.

Each R is a molecular segment independently selected from the groupconsisting of formula (1), formula (2), formula (3), and formula (4):

Each Z is a molecular segment independently selected from the groupconsisting of formula (5), formula (6), formula (7), formula (8), andformula (9).

Each diamine-derived unit is a diamine-derived moiety independentlyselected from the group consisting of formula (A), formula (B), formula(C), formula (D), formula (E), formula (F), formula (G), and formula(H):

Each X, X₁, X₂, X₃, X₄, X₅, X₆, X₇, and X₈ is independently selectedfrom the group consisting of hydrogen, an aromatic group, and a straightor branched C₁ to C₆ alkyl group. Each R_(a) is a straight or branchedC₁ to C₆ alkyl group having either a terminal hydroxyl group, a terminalcarboxylic acid group, or a terminal carbon to carbon double bond. EachZ′ is a molecular segment selected from the group consisting of formula(a), formula (b), formula (c), and formula (d):

Each Z″ is a moiety selected from the group consisting of formula (U)and formula (V):

Each X₉ is selected from the group consisting of hydrogen, a straight orbranched alkyl group having 1 to 6 carbon atoms, and a straight orbranched pefluoroalkyl group having 1 to 6 carbon atoms.

In one particular embodiment of the polyimide, R is the molecularsegment of formula (3), Z is the molecular segment of formula (5), 20%of the diamine-derived units are the diamine-derived moiety of eitherformula (A) or formula (B) and 80% of the diamine-derived units is thediamine-derived moiety of formula (C). When the diamine-derived moietyof formula (A) is the case, only one of X₁, X₂, X₃, and X₄ is a methylgroup and the others are hydrogen. When the diamine-derived moiety offormula (B) is the case, only one of X₅, X₆, X₇, and X₈ is a methylgroup and the others are hydrogen. This particular polymide is sold byEvonik Fibres GmbH under the trademark P84® (hereinafter the P84®polyimide). P84 has a CO₂ solubility at 35° C. and 10 bar pressureof >0.07 [cm³(STP)/cm³(polymer)-cmHg] and a glass transition temperatureof 316° C.

While the gas separation membrane(s) of the second gas separationmembrane stage 9 may have any configuration known in the field of gasseparation, typically they are formed as a flat film or as a pluralityof hollow fibers. In one embodiment, the separation layer of each of, orat least one of, the gas separation membranes of the second gasseparation membrane stage 9 is supported by a support layer where theseparation layer performs the desired separation while the support layerprovides mechanical strength. In the context of hollow fibers, theseparation layer is configured as a sheath surrounding a core made ofthe support layer. Regardless of the configuration of the membrane, thesupport layer may be any porous substrate known in the field of gasseparation membranes. Suitable membranes for the second gas separationmembrane stage are commercially available from Air Liquide AdvancedSeparations, a unit of Air Liquide Advanced Technologies, US.

PROPHETIC EXAMPLES Example

A computer simulation was performed in order to demonstrate the processof the invention. In the simulation, a feed gas with the following gascomposition was fed into a composite membrane including a PEBAXseparation layer and a PEEK support layer with methane permeance of 15GPU at 1000 psia and 30 C. The membrane cartridge exhibits a pressuredrop of only 37 psi.

FEED RAFF PERM F,MMSCFD(60F) 1.257 1 0.2567 PRESS, psia 1000 963.88 26.3CONCENTRATIONS, mol % WATER 0.1991 0.0043 0.9582 CARBON_DIOXIDE 44.964937.0415 75.8347 NITROGEN 0.4978 0.6132 0.0486 ETHANE 5.5858 5.99363.9967 PROPANE 3.6243 3.7977 2.9486 N-BUTANE 1.613 1.4971 2.0646N-PENTANE 0.4978 0.3258 1.1681 N-HEXANE 0.2091 0.1007 0.6313 METHANE42.8082 50.6262 12.3492

Comparative Example 2

A computer simulation was also attempted for the purpose ofdemonstrating a process that is not of the invention. A silicone basedmembrane with methane permeance of 120 GPU is used. The same feedcondition as in the Example was used for the calculation. The pressuredrop is so significant that the calculation did not converge.

While the invention has been described in conjunction with specificembodiments thereof, it is evident that many alternatives,modifications, and variations will be apparent to those skilled in theart in light of the foregoing description. Accordingly, it is intendedto embrace all such alternatives, modifications, and variations as fallwithin the spirit and broad scope of the appended claims. The presentinvention may suitably comprise, consist or consist essentially of theelements disclosed and may be practiced in the absence of an element notdisclosed. Furthermore, if there is language referring to order, such asfirst and second, it should be understood in an exemplary sense and notin a limiting sense. For example, it can be recognized by those skilledin the art that certain steps can be combined into a single step.

The singular forms “a”, “an” and “the” include plural referents, unlessthe context clearly dictates otherwise.

“Comprising” in a claim is an open transitional term which means thesubsequently identified claim elements are a nonexclusive listing i.e.anything else may be additionally included and remain within the scopeof “comprising.” “Comprising” is defined herein as necessarilyencompassing the more limited transitional terms “consisting essentiallyof” and “consisting of”; “comprising” may therefore be replaced by“consisting essentially of” or “consisting of” and remain within theexpressly defined scope of “comprising”.

“Providing” in a claim is defined to mean furnishing, supplying, makingavailable, or preparing something. The step may be performed by anyactor in the absence of express language in the claim to the contrary.

Optional or optionally means that the subsequently described event orcircumstances may or may not occur. The description includes instanceswhere the event or circumstance occurs and instances where it does notoccur.

Ranges may be expressed herein as from about one particular value,and/or to about another particular value. When such a range isexpressed, it is to be understood that another embodiment is from theone particular value and/or to the other particular value, along withall combinations within said range.

All references identified herein are each hereby incorporated byreference into this application in their entireties, as well as for thespecific information for which each is cited.

What is claimed is:
 1. A method for purification of natural gasincluding methane, CO₂, and C₃₊ hydrocarbons, comprising the steps of:feeding a feed gas consisting of the natural gas to a first gasseparation membrane stage comprising one or more membranes in series orparallel having a selective layer that is selective for C₃₊ hydrocarbonsover methane; withdrawing a first permeate stream from the membrane(s)of the first stage that is enriched in C₃₊ hydrocarbons in comparison tothe feed gas; withdrawing a first retentate stream from the membrane(s)of the first stage that is deficient in C₃₊ hydrocarbons in comparisonto the feed gas; feeding the first retentate stream to a second gasseparation membrane stage comprising one or more membranes in series orparallel having a selective layer that is selective for CO₂ overmethane; withdrawing a second permeate stream from the membrane(s) ofthe second stage that is enriched in CO₂ in comparison to the feed gas;and withdrawing a first retentate stream from the membrane(s) of thefirst stage that is deficient in CO₂ in comparison to the feed gas. 2.The method of claim 1, further comprising removing water from the feedgas prior to feeding the feed gas to the first gas separation membranestage.
 3. The method of claim 2, wherein said step of removing watercomprises feeding the feed gas to a molecular sieve adapted andconfigured to remove water from fluids.
 4. The method of claim 2,wherein said step of removing water comprises feeding the feed gas to adehydration gas separation membrane.
 5. The method of claim 1, furthercomprising the step of combusting the first and/or the second permeatestreams as a flare gas.
 6. The method of claim 1, wherein the feed gasis obtained from natural gas extracted from a subterranean or subseageological formation and said step further comprises injecting the firstand/or second stage permeate streams into the geological formation. 7.The method of claim 6, further comprising dehydrating the first and/orsecond permeate streams prior to injection into the geological formationsuch that a water content in the first and/or second permeate streaminjected into the geological formation is no more than 50 ppm (vol/vol).8. The method of claim 1, wherein the one or membranes of the first gasseparation membrane stage have a separation layer made of a copolymer orblock polymer of tetramethylene oxide, and/or propylene oxide, orethylene oxide.
 9. The method of claim 8, wherein a pressure dropbetween a pressure of the feed gas and a pressure of the retentate gasis less than 50 psi (3.45 bar).
 10. The method of claim 8, wherein apressure drop between a pressure of the feed gas and a pressure of theretentate gas is less than 30 psi (2.07 bar).
 11. The method of claim 8,wherein a pressure drop between a pressure of the feed gas and apressure of the retentate gas is less than less than 20 psi (1.38 bar).12. The method of claim 8, wherein the one or more membranes of thefirst gas separation membrane stage have a methane permeance of lessthan 68 gas permeation units (22.4 mol/m²·sec·Pa).
 13. The method ofclaim 8, wherein the one or more membranes of the first gas separationmembrane stage have a methane permeance of less than 34 GPU.
 14. Themethod of claim 8, wherein the one or more membranes of the first gasseparation membrane stage have a methane permeance of less than 20 GPU.15. The method of 8, wherein the one or membranes of the first gasseparation membrane stage have a separation layer made of a copolymer orblock polymer of the formula:

where PA is an aliphatic polyamide having 6 or 12 carbon atoms and PE iseither poly(ethylene oxide) poly(tetramethylene oxide).
 16. The methodof claim 8, wherein one or membranes of the first gas separationmembrane stage have a separation layer made of repeating units of thefollowing monomers:


17. The method of claim 8, wherein the one or more membranes of thefirst gas separation membrane stage are formed as flat films or as aplurality of hollow fibers.
 18. The method of claim 8, wherein each ofthe one or more membranes of the first gas separation membrane stage hasa separation layer that is supported by a support layer.
 19. The methodof claim 18, wherein each of the support layers is made of a polyimide,polysulfone, or polyether ether ketone.
 20. The method of claim 19,wherein each of the support layers is porous and is made of polyetherether ketone.
 21. The method of claim 1, wherein each of the membranesof the second gas separation membrane stage is made of celluloseacetate, a polysulfone, or a polyimide.
 22. A system for purification ofnatural gas including methane, CO2, and C₃₊ hydrocarbons, comprising: asource of natural gas; a first gas separation membrane stage comprisingone or more membranes fluidly in series or parallel communicating withsaid source, each membrane of the first gas separation membrane stagehaving a selective layer that is selective for C₃₊ hydrocarbons overmethane; and a second gas separation membrane stage comprising one ormore membranes in series or parallel fluidly communicating with aretentate outlet(s) of the membranes of the first gas separationmembrane stage so as to receive retentate from the first gas separationmembrane stage as a feed gas in the second gas separation membranestage, each membrane of the second gas separation membrane stage havinga selective layer that is selective for CO₂ over methane.
 23. The systemof claim 22, further comprising a water removal apparatus adapted andconfigured to remove water from the feed gas prior to feeding the feedgas to the first gas separation membrane stage.
 24. The system of claim23, wherein said water removal apparatus is a molecular sieve adaptedand configured to remove water from fluids.
 25. The system of claim 23,wherein said water removal apparatus is a dehydration gas separationmembrane.
 26. The system of claim 22, wherein each of the one ormembranes of the first gas separation membrane stage has a separationlayer made of a copolymer or block polymer of tetramethylene oxide,and/or propylene oxide, or ethylene oxide.
 27. The system of claim 26,wherein each of the one or membranes of the first gas separationmembrane stage exhibits a pressure drop between a pressure of the feedgas and a pressure of the retentate gas is less than 50 psi (3.45 bar).28. The system of claim 26, wherein each of the one or membranes of thefirst gas separation membrane stage exhibits a pressure drop between apressure of the feed gas and a pressure of the retentate gas is lessthan 30 psi (2.07 bar).
 29. The system of claim 26, wherein each of theone or membranes of the first gas separation membrane stage exhibits apressure drop between a pressure of the feed gas and a pressure of theretentate gas is less than less than 20 psi (1.38 bar).
 30. The systemof claim 26, wherein each of the one or membranes of the first gasseparation membrane stage exhibits a methane permeance of less than 68gas permeation units (22.4 mol/m²·sec·Pa).
 31. The system of claim 26,wherein each of the one or membranes of the first gas separationmembrane stage exhibits a methane permeance of less than 34 GPU.
 32. Thesystem of claim 26, wherein each of the one or membranes of the firstgas separation membrane stage exhibits a methane permeance of less than20 GPU.
 33. The system of claim 26, wherein the one or membranes of thefirst gas separation membrane stage have a separation layer made of acopolymer or block polymer of the formula:

where PA is an aliphatic polyamide having 6 or 12 carbon atoms and PE iseither poly(ethylene oxide) poly(tetramethylene oxide).
 34. The systemof claim 26, wherein one or membranes of the first gas separationmembrane stage have a separation layer made of repeating units of thefollowing monomers:


35. The system of claim 26, wherein the one or more membranes of thefirst gas separation membrane stage are formed as flat films or as aplurality of hollow fibers.
 36. The system of claim 26, wherein each ofthe one or more membranes of the first gas separation membrane stage hasa separation layer that is supported by a support layer.
 37. The systemof claim 36, wherein each of the support layers is made of a polyimide,polysulfone, or polyether ether ketone.
 38. The system of claim 37,wherein each of the support layers is porous and is made of polyetherether ketone.
 39. The system of claim 22, wherein each of the membranesof the second gas separation membrane stage is made of celluloseacetate, a polysulfone, or a polyimide.